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WO2006015277A1 - Dispositif de fond pour reguler le flux entrant au moyen d'un dispositif de fermeture - Google Patents

Dispositif de fond pour reguler le flux entrant au moyen d'un dispositif de fermeture Download PDF

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Publication number
WO2006015277A1
WO2006015277A1 PCT/US2005/027121 US2005027121W WO2006015277A1 WO 2006015277 A1 WO2006015277 A1 WO 2006015277A1 US 2005027121 W US2005027121 W US 2005027121W WO 2006015277 A1 WO2006015277 A1 WO 2006015277A1
Authority
WO
WIPO (PCT)
Prior art keywords
fluid
flow
flowspace
control device
wellbore
Prior art date
Application number
PCT/US2005/027121
Other languages
English (en)
Inventor
Craig Coull
Knut Henriksen
Erik Helsengreen
Original Assignee
Baker Hughes Incorporated
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Baker Hughes Incorporated filed Critical Baker Hughes Incorporated
Publication of WO2006015277A1 publication Critical patent/WO2006015277A1/fr

Links

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/14—Obtaining from a multiple-zone well
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/08—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/02—Down-hole chokes or valves for variably regulating fluid flow

Definitions

  • the invention relates generally to systems and methods for selective control of fluid flow into a production string in a wellbore.
  • the invention relates to devices and methods for actuating flow control valves in response to increased water or gas content in the production fluids obtained from particular production zones within a wellbore.
  • the invention relates to systems and methods for monitoring flow rate or flow density at completion points and adjusting the flow rate at individual production points in response thereto.
  • Inflow control devices are therefore used in association with sand screens to limit the rate of fluid inflow into the production tubing.
  • a number of such inflow governing devices are placed sequentially along the horizontal portion of the production assembly.
  • the inflow control device features a dual-walled tubular housing with one or more inflow passages laterally disposed through the inner wall of the housing.
  • a sand screen surrounds a portion of the tubular housing.
  • Production fluid will enter the sand screen and then must negotiate a tortuous pathway (such as a spiral pathway) between the dual walls to reach the inflow passage(s).
  • the tortuous pathway slows the rate of flow and maintains it in an even manner.
  • Inflow control devices currently lack an acceptable means for selectively closing off flow into the production tubing in the event that water and/or gas invades the production layer. Additionally, current inflow control devices do not have an acceptable mechanism for bypassing the tortuous pathway, so as to increase the production flow rate. It would be desirable to have a mechanism for selectively closing as well as bypassing the inflow control device. [0006] The present invention addresses the problems of the prior art.
  • the invention provides an improved system and method for controlling inflow of fluid into a production string.
  • the invention provides a downhole sand screen and inflow control device with a gas or water shut-off feature that can be operated mechanically or hydraulically from the surface of the well.
  • the device also preferably includes a bypass feature that allows the inflow control device to be closed or bypassed via shifting of a sleeve.
  • adaptive inflow control devices are positioned along a production string. Exemplary devices can be configured to activate the shut-off feature automatically upon detection of a predetermined gas/oil ratio (GOR) or water/oil ratio (WOR).
  • GOR gas/oil ratio
  • WOR water/oil ratio
  • the shut-off feature is automatically activated upon detection of fluid density changes or changes in the operating temperature of the inflow control device or flowing fluid.
  • the inflow control devices restrict but not totally shut off fluid flow. In other embodiments, the inflow control devices fully shut off fluid flow.
  • Figure 1 is a side, cross-sectional view of an exemplary multi-zonal wellbore and production assembly which incorporates an inflow control system in accordance with the present invention.
  • Figure IA is a side, cross-sectional view of an exemplary open hole production assembly which incorporates an inflow control system in accordance with the present invention.
  • Figure 2 is a side, cross-sectional view of a first exemplary sand screen flow control device in a valve-open configuration.
  • Figure 3 is a side, cross-sectional view of the sand screen flow control device shown in Figure 2, now in a valve-closed configuration.
  • Figure 4 is a side, cross-sectional view of a second exemplary sand screen flow control device in a valve-open configuration.
  • Figure 5 is a side, cross-sectional view of the sand screen flow control device in a valve-closed configuration.
  • Figure 6 is a side, cross-sectional view of the sand screen flow control device in a bypass configuration.
  • Figure 7 illustrates the use of distributed temperature sensing devices for the conduct of flow control within a production assembly.
  • Figure 7A is a graph of measured temperature vs. location.
  • Figure 8 illustrates an exemplary valve actuator in an initial closed position.
  • Figure 9 depicts the actuator shown in Figure 8 now in an open position.
  • Figure 10 illustrates an exemplary temperature-actuated cone valve assembly in an initial open position.
  • Figure- 14 illustrates the cone valve assembly of Figure 10 now in a closed position.
  • Figure 12 depicts an exemplary heat actuated valve assembly with a hydraulic backup system, in an initial open position.
  • Figure 13 illustrates the valve assembly shown in Figure 12 now having been closed via temperature change.
  • Figure 14 shows the valve assembly shown in Figures 12 and 13 remaining in the closed position following subsequent change of temperature.
  • Figure 15 depicts the valve assembly shown in Figures 12-14 having been reopened by the hydraulic backup system.
  • Figure 16 shows an exemplary valve assembly that is actuated in response to changes in fluid density with the valve in a closed position.
  • Figure 17 shows the valve assembly of Figure 16, now with the valve in an open position.
  • Figure 18 shows embodiments of inflow control devices used in conjunction with a main wellbore having at least one branch wellbore.
  • Figure 19 shows embodiments of inflow control devices used in conjunction with a main wellbore and an adjacent ditch wellbore.
  • Figure 1 depicts an exemplary wellbore 10 that has been drilled through the earth 12 and into a pair of formations 14, 16 from which it is desired to produce hydrocarbons.
  • the wellbore 10 is cased by metal casing, as is known in the art, and a number of perforations 18 penetrate and extend into the formations 14, 16 so that production fluids may flow from the formations 14, 16 into the wellbore 10.
  • the wellbore 10 has a deviated, or substantially horizontal leg 19.
  • the wellbore 10 has a late-stage production assembly, generally indicated at 20, disposed therein by a tubing string 22 that extends downwardly from a wellhead 24 at the surface 26 of the wellbore 10.
  • the production assembly 20 defines an internal axial flowbore 28 along its length.
  • An annulus 30 is defined between the production assembly 20 and the wellbore casing.
  • the production assembly 20 has a deviated, generally horizontal portion 32 that extends along the deviated leg 19 of the wellbore 10.
  • At selected points along the production assembly 20 are production nipples.34...
  • each production nipple 34 is isolated within the wellbore 10 by a pair of packer devices 36. Although only two production nipples 34 are shown in Figure 2, there may, in fact, be a large number of such nipples arranged in serial fashion along the horizontal portion 32.
  • Each production nipple 34 features an inflow control device 38 that is used to govern the rate of inflow into the production assembly 20.
  • the inflow control device 38 may have a number of alternative constructions that ensure selective operation and controlled fluid flow therethrough.
  • the inflow control devices are responsive to control signals transmitted from a surface and/or downhole location.
  • the inflow control devices are adaptive to the wellbore environment. Exemplary adaptive inflow control devices (or "AICD") can control flow in response to changes in ratios in fluid admixtures, temperatures, density and other such parameters.
  • Figure 1 a illustrates an exemplary open hole wellbore arrangement 10 ' wherein the inflow control devices of the present invention may be used. Construction and operation of the he open hole wellbore 10' is similar in most respects to the wellbore 10 described previously. However, the wellbore arrangement 10' has an uncased borehole that is directly open to the formations 14, 16. Production fluids, therefore, flow directly from the formations 14, 16, and into the annulus 30 that is defined between the production assembly 20'and the wall of the wellbore 10'. There are no perforations 18, and typically no packers 36 separating the production nipples 34.
  • a first exemplary inflow control device 38 that includes an tubular housing 40 which defines an interior flowbore 41. Fluid flow apertures 42 are disposed through the housing 40. A sleeve 44 surrounds a portion of the housing 40 and defines a fluid flowspace 46 therein. A helical thread 48 surrounds the housing and winds through the flowspace 46. A porous sand screen 50 surrounds one end portion of the housing 40. A hydraulic chamber 52 is disposed within the housing 40.
  • First and second hydraulic control lines 54, 56 are operably interconnected with the hydraulic chamber 52 to supply and remove hydraulic fluid therefrom.
  • the hydraulic control lines 54, 56 extend to a remote hydraulic fluid supply .(not shown), which_may be located at the surface 26.
  • the closing sleeve 58 is slidably retained within the flowbore 41 of the housing 40.
  • the closing sleeve 58 includes an annular ring portion 60 and a plurality of axially extending fingers 62.
  • the annular ring portion 60 at least partially resides within the hydraulic chamber 52.
  • the fingers 62 are shaped and sized to cover the inflow apertures 42.
  • the inflow control device 38 is normally in the open position shown in Figure 2, wherein production fluid can pass through the sand screen 50 and into the flowspace 46.
  • the production fluid negotiates the tortuous path provided by thread 48 and enters the flowbore of the housing 40 via apertures 42.
  • the device 38 may be closed against fluid flow by shifting the closing sleeve 58 to the closed position shown in Figure 3 so that the fingers 62 cover the apertures 42.
  • the sleeve 58 is shifted to the closed position by injecting pressurized hydraulic fluid through hydraulic control line 54. The fluid acts upon the ring portion 60 of the sleeve 58 to urge it axially within the flowbore 41.
  • FIG. 4-6 illustrate an alternative exemplary inflow control device 70. Except where noted, construction and operation of the inflow control device 70 is the same as the inflow control device 38. Portions of the inflow control device 70 are shown in schematic fashion for clarity. Fluid bypass ports 72 are disposed through the tubing section 38 upstream of the helical thread 48. A plurality of plates 74 are secured in a fixed manner outside of the housing 40 and within the flowspace 46.
  • Fingers 76 also reside within the flowspace 46 and are secured to a sliding sleeve valve member (not shown) similar to the sleeve member 58 described earlier.
  • the fingers 76 are shaped and sized to slide between the plates 74 in an interlocking fashion. Initially, the fingers 76 cover bypass ports 72, as Figure 4 depicts.
  • the fingers 76 may be affixed to an annular ring (not shown), similar to the annular ring 60 described earlier, and moved within the flowspace 46 by selective pressurization of hydraulic chamber 52, via control lines 54, 56.
  • the inflow control device 70 is moveable between three positions, illustrated by Figures 4, 5, and 6, respectively.
  • the first position Figure 4
  • the inflow -control device is configured to provide controlled flow into the housing 40. Fluid enters the sand screen 50 and proceeds along the flowspace 46 and between plates 74 to helical thread 48. Upon exiting the threaded portion 48, the fluid can enter the housing 40 via apertures 42. This is the typical mode of operation for the inflow control device 70. If it desired to close off fluid flow through the device 70, this is accomplished by moving the fingers 76 axially to the position shown in Figure 5. In this position, the fingers 76 interlock with plates 74 to block fluid flow along the flowspace 46. Production fluid can no longer enter the housing 40 via apertures 42. T/US2005/02712!
  • the inflow control device 70 also includes a third configuration, a bypass configuration, that allows production fluid to enter the housing 40 without passing through the flow restricting helical thread 48.
  • the bypass configuration illustrated in Figure 6, is used when it is desired to increase flow through the device 70 to a greater extent than the normal open position allows.
  • the fingers 76 are moved axially to the position shown in Figure 6, such that the bypass ports 72 become unblocked by the fingers 76.
  • Production fluid can now flow into the sand screen 50 and along the flowspace 46 to the bypass ports 76, wherein it will enter the housing 40.
  • Figures 7 and 7 A illustrate the application of a distributed temperature sensing system to control fluid flow into the production string 20.
  • Figure 7 depicts a production string 20 with three production nipples 38a, 38b, 38c which incorporate inflow control devices of the types described previously.
  • An optical fiber cable 80 extends along the production string 20 in contact with each of the production nipples 38a, 38b, 38c.
  • the optical fiber cable 80 extends upwardly to the surface 26 and is a component of a distributed temperature sensing (DTS) system.
  • DTS systems are known systems that are used to detect and monitor operating temperature and display measured temperature in a linearized fashion.
  • Figure 7A depicts an exemplary DTS system graphic display wherein temperature is measured at each of the production nipples 38a, 38b, 38c. The operating temperature of the production nipples3.8a, 38b, 38c will increase as flow rate into the production string
  • Fluid flow rate will increase substantially as the gas/oil ratio (GOR) and/or water/oil ratio (WOR) within the production fluid rises.
  • GOR gas/oil ratio
  • WOR water/oil ratio
  • an increased temperature will indicate a higher gas and/or water content.
  • the measured temperature is depicted, by location, as graph line 82 and compared to a baseline normal operating temperature range 84.
  • FIGS 8 and 9 depict an exemplary automatic valve actuator 86 which may be used with the first hydraulic control line 54 of the inflow control device 38 in order to automatically close fluid flow in the event of increased operating temperatures associated with a high GOR or WOR.
  • Hydraulic line 54 contains pressurized hydraulic fluid, and the actuator 86 is disposed between this fluid and the hydraulic chamber 52 described earlier.
  • the actuator 86 includes an outer housing 88 that encloses a flowpath 90.
  • An expandable element 92 is retained within the flowpath 90 and is fashioned of a heat- sensitive shape memory alloy, of a type known in the art to expand in size or shape under high temperatures and to retract to its original size or shape in response to cooler temperatures.
  • the actuator 86 also includes a rod 94 and a ball member 96 that is seated upon a ball seat 98.
  • valve actuation element 86 When the production nipple 38 is operating at or below expected operating temperatures, the valve actuation element 86 is in the position shown in Figure 8, and the ball member 96 blocks passage of pressurized fluid into the hydraulic chamber 52. However, when the operating temperature rises past a predetermined limit, the element 92 expands, urging the rod 94 against the ball member 96 and opening the flowpath 90. Pressurized fluid will enter the hydraulic chamber 52 and cause the sleeve member 58 to close the fluid apertures 42 to flow, as described previously. When the operating temperature has returned to normal or below normal, the element 92 will retract to its initial shape or size,_allowing the ball member 96 to once again block fluid flow into the hydraulic chamber 52.
  • FIGS 10 and 11 depict an exemplary heat-sensitive valve element 100 that may be used to selectively block the flow apertures 42 during high operating temperatures.
  • the valve element 100 includes a valve closure member 102 that is interconnected with a valve base 104 by an expandable element 92.
  • the valve closure member 102 is shaped and sized to be complimentary to the aperture 42. While at normal operating temperatures, the valve element 100 is in the configuration shown in Figure 10, with flow through the aperture 42 occurring. When the operating temperature rises above 2005/027121
  • the expandable element 92 expands to bring the closure member 102 into sealing engagement with the aperture 42, thereby closing off flow through the aperture 42.
  • the expandable element 92 return to the configuration shown in Figure 10, with flow through the aperture 42 once again occurring.
  • FIGs 12-15 depict a further exemplary automatically actuated valve element 110 having a hydraulic backup feature.
  • the valve element 110 is constructed similar to the valve element 100 described previously.
  • the valve closure member 112 includes an engagement portion 114.
  • a hydraulic chamber 116 and actuation arm 118 are also associated with the valve element 110.
  • the actuation arm 118 is moved axially by selective pressurization of portions of the hydraulic chamber 116.
  • the valve element 110 is initially in the configuration shown in Figure 12. When the operating temperature rises past a predetermined level, the expandable element 92 expands to urge the valve closure member 112 into engagement with the aperture 42, closing it against fluid flow therethrough (see Figure 13).
  • the expandable element 92 will retract and withdraw the closure member 112. In the configuration shown in Figure 14, however, the closure member 112 has failed to retract.
  • the hydraulic chamber 116 may then be pressurized to cause the actuating arm 118 to move axially, engaging the engagement portion 114 to pull the closure member 112 away from the aperture 42, restoring flow therethrough.
  • FIGS 16 and 17 illustrate an exemplary valve assembly 120 that is responsive to changes in production fluid density.
  • An exemplary density-sensitive valve assembly 120 is incorporated into a section of an inflow control device 38 or 70 between the sand screen 50 and the fluid apertures 42.
  • the valve assembly 120 is made up of a pair of valve members 122, 124 which reside within the flowspace 46 defined between the inner housing 40 and the outer sleeve 44 and are free to rotate within the flowspace 46.
  • the valve members 122, 124 may be made of bakelite, Teflon® hollowed steel or similar materials that are fashioned to provide the operable density parameters that are discussed below.
  • Each of the valve members 122, 124 includes an annular ring portion 126.
  • the first valve member 122 also includes an axially extending float portion 128.
  • the second 27121 is incorporated into a section of an inflow control device 38 or 70 between the sand screen 50 and the fluid apertures 42.
  • the valve assembly 120 is made up of a
  • valve member 124 includes an axially extending weighted portion 130.
  • the weighted portion 130 is preferably fashioned of a material with a density slightly higher than that of water. The presence of the weighted portion 130 ensures that the second valve member 124 will rotate within the flowspace 46 so that the weighted portion 130 is in the lower portion of the flowspace 46 when in a substantially horizontal run of wellbore.
  • the float portion 128 of the first valve member 122 is density sensitive so that it will respond to the density of fluid in the flowspace 146 such that, in the presence lighter density gas or water, the valve member 122 will rotate within the flowspace 46 until the float portion 128 lies in the upper portion of the flowspace (see Figure 17). However, in the presence of higher density oil, the valve member 122 rotates so that the float portion 128 lies in the lower portion of the flowspace 46 (see Figure 16).
  • the ring portion 126 opposite the float portion 128 contains a first fluid passageway 132 that passes axially through the ring portion 126.
  • a second fluid passageway 134 passes axially through the ring portion 126 and the weighted portion 130.
  • restriction to fluid flow can be achieved with a density-sensitive device that uses linear directed movement that closes or minimized flow ports; e.g., an annular mounted density-sensitive plugs or flapper.
  • inflow control devices ICD' s
  • ICD' s inflow control devices
  • branch bores 200 are drilled from a main bore 202.
  • ICD's 204 are positioned adjacent or upstream of junctions 206 between the main bore 202 and branch bores 202.
  • the ICD's 204 can control the commingled flow from each of the branch bores 202.
  • one or more ditch wells 210 are drilled adjacent a main wellbore 22.
  • the ditch well 210 have trajectories selected to drain hydrocarbons from the formation F and direct the drained fluid to main wellbore 212.
  • the ditch wells can be 21
  • the ICD's 214 are distributed along the main bore at selected locations to control or otherwise modulate the flow of commingled fluids. Additionally, in some applications, the ICD's 214 can be positioned in the ditch well 210 control flow from the ditch well 210 and surrounding formation to the main wellbore 212. In any event, the ICD restricts or permits flow based on the nature of the produced fluid. The ICD's can be configured to restrict the flow of commingled fluid based a parameter such as water cut as described previously.
  • the inflow control devices are deployed in conjunction with a screen, isolation devices such as packers, sealing elements or other devices that provide zonal isolation and flow control in a manner previously described. A separate inflow control device can be utilized adjacent each junction.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Flow Control (AREA)

Abstract

L'invention concerne un système et un procédé pour réguler le flux d'un fluide pénétrant dans une colonne de production. Dans certains modes de réalisation, un dispositif de fond, comprenant un tamis à sable et une régulation de flux et doté d'un dispositif de fermeture de gaz ou d'eau, peut être piloté de manière mécanique ou hydraulique à partir de la surface du puits. Ce dispositif comporte de préférence un dispositif de dérivation qui permet de fermer le dispositif de régulation de flux entrant ou de le contourner par déplacement d'un manchon. Dans d'autres modes de réalisation, le dispositif de régulation de flux peut être adapté à des changements de conditions de forage telles que la composition chimique, la densité fluidique et la température. Des exemples de dispositifs de régulation de flux adaptatifs comportent des éléments conçus pour réguler le flux en fonction de changements dans le rapport gaz/pétrole, dans le rapport eau/pétrole, dans la densité fluidique et/ou la température opérationnelle du dispositif de régulation de flux. Dans encore d'autres modes de réalisation, des dispositifs de régulation de flux entrant servent à réguler le flux de fluides mélangés drainés par deux trous de forage ou plus.
PCT/US2005/027121 2004-07-30 2005-07-29 Dispositif de fond pour reguler le flux entrant au moyen d'un dispositif de fermeture WO2006015277A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US59249604P 2004-07-30 2004-07-30
US60/592,496 2004-07-30

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US7409999B2 (en) 2008-08-12

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